Application of degradable polymers in sand control

ABSTRACT

Degradable polylactic or polyhydroxyalkanoate polymers may be used to viscosify aqueous fluids for use in wells. Sand control screen or liner can be coated with a solid degradable polymer during placement in a well. Mechanical changes or flow changes in a well can be caused by solid degradable polymer that changes physical properties after it is placed in a well. Parts of devices or entire devices can be made of solid degradable polymer that converts to a fluid after selected times in an aqueous environment in a well.

This application is a divisional application of application Ser. No.11/804,612, filed May 18, 2007, now U.S. Pat. No. 7,625,846, which is acontinuing application of application Ser. No. 10/845,737, filed May 14,2004, now abandoned, which claims the benefit of U.S. ProvisionalApplication No. 60/470,738, filed May 15, 2003.

BACKGROUND OF THE INVENTION

1. Field of the Invention

This invention pertains to mechanical and chemical operations in wells.In one embodiment, polymer and method of preparing viscous fluid for usein wells is provided. In another embodiment, material and methods areprovided for coating of sand control screens used in wellbores. Inanother embodiment, this invention pertains to delayed mechanical orflow changes in a wellbore after equipment is placed in the well. Inanother embodiment, this invention pertains to equipment that is placedin a wellbore and is degraded in the wellbore by contact with aqueousfluid.

2. Discussion of Related Art

A large number of mechanical and chemical operations are carried out inand around wells. Most of these wells are used for producinghydrocarbons from the earth. They are located at depths ranging from afew hundred feet below the surface of the earth to more than 30,000feet. The temperature at the bottom of the wells likewise varies over awide range—from about 100° F. to more than 400° F.

After the hole is drilled in the earth in the process of constructing awell, the process of placing casing in the well and cementing it inplace is commenced. Mechanical devices to aid in the cementing processmay be placed on the outside of the casing before it is placed in thehole. Instruments and communication cables may be placed on the casing.Multiple lateral holes may be drilled from a single hole and casing maybe placed in each. When casing has been cemented, the process of“completing” the well may begin. This involves forming holes(“perforating”) the casing opposite an interval of a formation wherefluids are to be produced or injected and, in most cases, placing tubingin the well. Various types of mechanical equipment may be placed in thewellbore, for safety, flow control and other purposes. Viscous,non-damaging fluids having a selected specific gravity are needed inwells during completion operations. In many wells various types oftreatment fluids are then injected into the well to provide greatercapacity of the well to produce hydrocarbons, in processes such ashydraulic fracturing and acidizing, called “stimulation” processes. Theuse of a degradable polymer in the form of ball sealers or particulatesto divert fluid or control fluid loss from a well during completion orstimulation operations has been disclosed. (U.S. Pat. No. 4,716,964).

In some wells, the formation where hydrocarbons are found has lowmechanical strength, which can result in “sand” being produced into thewell along with hydrocarbons. The well then requires application of a“sand control” process. One of these processes requires placing a“screen” in the well. The solid particles (cuttings) and drilling fluidin the well may plug or partially plug the screen as it is placed in awell. This problem can be particularly severe in directional orhorizontal wells. A recent U.S. Patent Application Publication(US2002/0142919 A1) discloses screen coatings that melt or dissolvewithin a wellbore and release reactive materials effective in degradingor dissolving materials that could plug a screen. The problem of screenplugging during placement was recognized many years ago (“DownholeProtection of Sand Control Screens,” Society of Petroleum EngineersPaper No. 8803, 1980).

In well operations used for completing or stimulating a well, viscousfluids may be used. In most cases, it is desirable that the fluid becomelower viscosity with time after it is placed in a well or formationaround a well. When the fluid becomes low viscosity it should contain nosignificant amount of solid or gel material. One example application ofsuch fluids is hydraulic fracturing of wells. U.S. Patent ApplicationPublication 2003/0060374A1, which is hereby incorporated by referenceherein, discloses the use of highly concentrated degradable polymers inan aqueous liquid in such application. As explained in that Publication,there is a need for fracturing fluids that degrade to low viscositywithout leaving a residue.

Other applications where a viscous fluid may be injected into a well orused in a well include completion fluid, performing fluids and fluidsfor carrying gravel (sand) into a well. These fluids are preferablysolids-free and degradable to low viscosity fluid having low solid orgel content that could degrade permeability of a porous rock. Otherapplications where a viscous liquid in a wellbore may be advantageousinclude a completion or workover fluid that is placed in a well duringrunning of a mechanical device into the well or other mechanicaloperation in the well. These fluids may contain high concentrations ofcompounds soluble in water that increase the density of the fluid, suchas sodium bromide or zinc bromide, or solid weighting materials. Theviscosifying material in the fluids should degrade with time and leavelittle or no residue of solid or gel that could damage the permeabilityof a formation around the well.

A wide variety of mechanical devices are placed in wells duringcompletion and workover operations. These devices are used to controlfluid flow, to seal around tubulars in the well, to perform measurementsof physical or chemical parameters and various other purposes. Thesedevices may be needed for only a limited time and then an operator maywish to have them no longer effective or to no longer have mechanicalstrength. For example, packers, bridge plugs and cement retainers may beneeded for a limited time in a well. There may be a need to release amechanical device or open a port after a selected time in aninaccessible portion of a wellbore, such as in an annulus betweentubular strings, where an aqueous fluid is located.

What are needed in a variety of well operations or processes are viscousliquids that degrade to low viscosity liquid at a predictable rate andleave low amounts of solid or gel residue, a degradable coating forscreens, and solids that lose mechanical strength at a predictable ratein the presence of an aqueous liquid to allow delayed flow or mechanicalchanges in inaccessible locations in wellbores or degradation ofmechanical equipment that is no longer needed in a wellbore.

SUMMARY OF THE INVENTION

Degradable polymers and methods for using in wells are provided. In oneembodiment, the degradable polymer is used to viscosify fluids used inwellbore operations. In another embodiment, the degradable polymer isused to protect a sand control screen from plugging as it is placed in awell. In yet another embodiment, the degradable polymer is used to delayto a selected range of time a change in mechanical or flow conditions ina well. In yet another embodiment, the solid degradable polymer is usedto form equipment that is temporarily used in well operations.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows a sketch of a cased well having tubing and the surroundingformation.

FIG. 2 shows a cross-section of a wire-wrapped sand control screenprotected by a degradable polymer.

FIG. 3 shows spring-loaded apparatus in the annulus between tubing andcasing in a well that is released by degradation of a degradablepolymer.

DETAILED DESCRIPTION OF THE INVENTION

Referring to FIG. 1, wellbore 10 penetrates formation 20 where fluid isto be produced or injected. Wellbore 10 has casing 12 extending throughformation 20, casing 12 being cemented in place by cement sheath 17.Perforations 14 have been formed through the wall of casing 12 andcement sheath 17 into formation 20. Perforations 14 may extend over theentire thickness of formation 20 or may extend only over a selectedinterval of formation 20 less than the total thickness surroundingwellbore 10. In some wells, hydraulic fracture 30 may have been formedaround wellbore 10 by a previous treatment employing conventionalfracturing fluid and proppant, using techniques well-known in industry.Alternatively, fracture 30 may not be present. Tubing 16 may have beensuspended inside casing 12 and packer 18 may have been set near thebottom of tubing 16 to seal the annulus between tubing 16 and casing 12.Packer 18 may not be present in some wells, tubing 16 may not be presentin some wells, and even casing 12 may not be present in some wells,although most wells in which the methods disclosed here will be appliedcontain casing and tubing with a packer near the bottom of the tubing.Packer 18 may have a controllable port for circulating fluids in theannulus of the well (not shown) or tubing 16 may be releasable frompacker 18 to allow circulation of fluids down the tubing and up thetubing-casing annulus. Alternatively, tubing 16 may contain a slidingsleeve above and near packer 18, which is well known in industry.

In an embodiment for damage removal near wellbore 10, the materials andmethods disclosed in U.S. Patent Application Publication 2003/0060374A1,which is incorporated by reference, may be used to form short hydraulicfracture 32 around wellbore 10 by injecting the degradable fracturingfluid at a pressure above the fracturing pressure of formation 20. Thefracturing fluid disclosed herein is similar to fracturing fluidsnormally used, in which a polymer is dispersed in a liquid to increaseviscosity of the liquid, and has rheological properties similar to theconventional fracturing fluids. The fracturing fluid disclosed herein isa more dilute mixture of the degradable polymer contained in the“polymer phase” disclosed in the cited '374 Publication, and it may beused to form hydraulic fracture 30 or hydraulic fracture 32, as shown inFIG. 1. The preferred degradable polymer is a polymer that ispolymerized to a preferred range of molecular weight or is degraded(decreased in molecular weight) by reaction with water (herein“water-degradable”) to desirable range of molecular weight for use in awellbore fluid. The polymer is dispersed or dissolved in an aqueousliquid and then degrades to mostly water-soluble monomers or oligomersover a period of time in the presence of water.

The use of solid water-degradable polymers in wells is known. Their usein wellbores for diverting fluids between perforations or decreasingfluid loss from a hydraulic fracture when particles of the polymer aredispersed in fracturing fluid has been disclosed. U.S. Pat. No.4,716,964 discloses use of such polymers in “ball sealers” and as afluid loss material in well treating fluids. Ball sealers are rigidspheres added to a well treatment fluid to seal on perforations anddivert flow of the treatment fluid to other perforations. Fluid lossadditives are finely divided solid polymer particles that are dispersedin the fracturing fluid or other well treatment fluid and injected intoa well. The polymers disclosed in the '964 patent include poly(D,L-lactide) and copolymers of lactide and glycolide.

A significant amount of research and development has been performed inrecent years to commercialize polymers that degrade to water-solublechemicals. In addition to the polylactic acid (PLA) polymerscommercialized by Cargill Dow Polymers LLC, other degradable polymers,including other polyesters (based on polyethylene terephthalate, forexample), starches, polycaprolactone, polyhydroxybutyrates and blends ofthese materials have been developed. Properties of lactide polymers arereviewed in the article “Properties of lactic acid based polymers andtheir correlation with composition,” A. Sodergard and M. Stolt, Prog. inPol. Sci., July, 2002. Further development is underway for otherdegradable or biodegradable polymers. Metabolix, Inc. of Cambridge,Mass., for example, is developing a family of degradable polymers knownas PHAs (polyhydroxyalkanoates). PHA polymers (also polyesters) areproduced by photosynthesis, either indirectly using highly efficientfermentation processes, or directly in plant crops. The price of thesepolymers is expected to decrease to about the cost of oil-derivedpolymers within a few years. The properties of such polymers can beadjusted by molecular weight distribution, crystallinity, co-polymersand additives to control physical properties and degradation time underselected environments. Polymers such as PLAs and selected PHAs, such aspolyhydroxybutyrate, can be optimized for the applications disclosedherein by varying manufacturing methods and conditions.Polyhydroxybutyrate will be, in general, more stable to degradation thanPLA. Different polymerization variables can be controlled duringmanufacture and/or compounding to provide desirable degradation timesunder a broad range of environmental conditions that exist inunderground formations. The PHAs can also be optimized by varyingmicrobes used in the fermentation processes.

Degradation of solid polyesters occurs first by water penetrating thebulk of the polymer, preferentially attacking the chemical bonds in theamorphous polymer and converting long chains into shorter water-solublefragments. Degradation rates can be controlled by incorporation ofvarious additives. The control of properties of thermoplastic polymersby addition of plasticizers and other additives is well known. Ofcourse, exposure of the plastics to moisture before their use can becontrolled to prevent premature degradation. Biodegradable polymers mayalso be degraded by enzymes, which may be used to contact the polymers,as is known in the art. If there is need to increase the degradationrate of polymers left in a wellbore, for example, heating of thepolymers in the wellbore can be used to increase degradation rate of thepolymer may be contacted by a solution containing enzymes. The Sodergardand Stolt article, cited above, discusses biodegradation of degradablepolymers, including polyesters, and polylactic acid in particular. Thedegradation rate (hydrolysis) of polylactic acids may be increasedsignificantly by enzymes pronase, proteinase K and bromelain.

Since water is always present in hydrocarbon reservoirs and aqueousliquids are usually used in wellbore operations, there is nearly alwaysa mechanism to cause polymer degradation of water-degradable polymers ina wellbore or in a reservoir. Rate of polymer degradation will dependprimarily on polymer composition, polymer structure and temperature. Forany degradable polymer selected, degradation time can be determined byheating a sample of the polymer to be injected. A water-degradablepolymer can be exposed to an aqueous liquid and subjected to a thermalhistory simulating the conditions the polymer would experience in a wellwhere it is to be used. The thermal history of the polymer as it isplaced in a wellbore or injected down a wellbore and resides in thewellbore or the subsurface formation while degrading may be simulated inlaboratory tests to select the polymer or copolymers and any additivesused with the polymer.

A fracturing fluid, completion or workover wellbore fluid, fluid forcarrying gravel into a fracpack or gravel pack or fluid for other welloperations may be formed by polymerizing lactic acid to PLA or formingPHA or other biopolymer having a range of molecular weight that can bedissolved in an aqueous liquid to be used in the well operation andadding the resulting polymer to aqueous liquid. If the molecular weightof the manufactured PLA or PHA is too high to allow solubility in theaqueous liquid, the molecular weight of the polymer can be decreased byapplying heat to the polymer in the presence of water. For example,steam or hot water may be applied to solid or liquid polymer for aselected time to obtain a molecular weight range of the polymer suchthat it can be dissolved in the aqueous liquid to be used in a welloperation. Polymer having a desired range of molecular weight may bestabilized or partially stabilized against further decrease of molecularweight until it is used in a well operation by removing water from thepolymer (drying) or by lowering the temperature of the polymer in anaqueous fluid.

The well treatment fluid disclosed herein may be placed in wellbore 10(FIG. 1) by pumping the viscous polymer down the well from the surfaceas fluids of the prior art are pumped. The polymer is added to theaqueous well treatment fluid to a concentration selected to achieve thedesired range of viscosity of the treatment fluid. The polymer may becross-linked to increase the effective viscosity of the solution usingwell known cross-linking agents.

The properties of polylactide are affected by the isomeric content ofthe polymer. In addition to the D,L-polylactide disclosed in U.S. Pat.No. 4,716,964, discussed above, which is a racemic mixture, apolylactide formed from 13 percent D-isomer and 87 percent L-isomer,available from Cargill-Dow, is primarily amorphous in the solid stateand degrades to form a viscous liquid in the presence of water.Preferably, a polymer that is amorphous or not highly crystalline in thesolid state will be used to form the well treatment fluid of thisinvention. At the boiling point of water, viscous liquid formed fromsolid pellets of the 13 percent D-isomer material, whereas a polylactidecontaining only about 6 percent D-isomer did not degrade to a viscousliquid under the same conditions but degraded to a crystalline polymer.Therefore, the relative amount of D- and L-isomer should be selected inthe range from about 10 percent to about 90 percent of an isomer or in arange to form an amorphous or not highly crystalline polymer. It isbelieved that isomer compositions in this range form an amorphouspolymer and the lower molecular weight polymers and the oligomers formedduring degradation form less crystalline material, allowing formation ofthe viscous liquid during degradation of the polymer. The viscous liquidcan be diluted to form a solution having desired rheological properties.Amorphous forms of other polyesters are preferred for the same reasons.

In addition to the application of degradable polymers to form viscousaqueous liquid for use in wells, the polymers may be applied in thesolid form in a variety of processes or methods. The primarycharacteristic of the polymer in some of these applications is that themechanical properties of the polymer change in a predictable manner withtime in the presence of water or an aqueous liquid. If desired, aninitial solid polymer may finally go in solution in the aqueous phase.In some applications, only a decrease in mechanical properties (modulus,bending strength, tensile or compressive strength, for example) in apredictable time range may be necessary for application of the polymer.In other applications, the polymer may maintain its mechanicalproperties until it is employed, then decrease in mechanical propertiesand become a low-strength gel or low-strength crystalline solid orbecome soluble in an aqueous phase in a wellbore.

In one embodiment of the invention disclosed herein, degradable polymeris used to coat a sand control screen or slotted liner before it isplaced in a well. Such an application is described in a recentlypublished U.S. Patent Application (No. 2002/0142919A1), which is herebyincorporated by reference. The material used to coat the screen iscalled a “binder.” In the '919 Publication, it is disclosed that thebinder may contain components that “react with potentially pluggingmaterials in the near wellbore area” when the components are released asthe binder melts or dissolves. Such components are well known (scale,paraffin and clays, for example). The use of wax and soluble solids as abinder is disclosed. The use of a water-degradable solid polymer thatdecreases in molecular weight with time is not disclosed.

FIG. 2 shows a cross-section of a wire-wrapped sand control screen. Thescreen includes basepipe 130, stand-offs 134 and wire 136. Washpipe ortail pipe 132 is shown inside the screen. The protective coating on thescreen is designated 122. It should be understood that a screen isillustrated, but a perforated liner or permeable sintered medium may beprotected by a protective coating such as coating 122.

The use of PLA, PHA and other polyester polymers makes possible a timeddegradation of the coating, rather than the employment of temperaturealone or dissolution in a fluid as disclosed in the '919 Publication.The properties of the polyester may be selected to maintain sufficientmechanical strength to prevent displacement of the polymer from thescreen as it is placed in a well. This time may be from several hours todays, depending on the time required to place the coated screen in awell. An example of the decrease in molecular weight of poly(DL-lactide) with time is provided in the paper “Further investigationson the hydrolytic degradation of poly (DL-lactide),” Biomaterials 20(1999) 35-44. The data in the paper were obtained at 37° C. and at 60°C. As can be noted in the U.S. Pat. No. 4,716,964, referenced above, therate of degradation is much more rapid at temperatures more typical ofthe temperature in wells. The polymer coating initially should have amelting point higher than the temperature expected in the well. Thepolymer should degrade to form a material that can be displaced from thewell. If the polymer should flow outwardly from the screen, the polymershould not permanently damage permeability of the gravel placed in thewell. Some or the entire polymer may be produced from the well as aviscous liquid. The initial strength of the solid polymer should besufficient to prevent flow across the screen, in the area where thepolymer is applied, under pressure differentials across the screen as itis placed in the well. The polymer coating may be used, for example, toprevent flow through only selected areas of the screen as it is put in awell. To increase initial strength of the polymer, a composite may beformed with the polymer by incorporating particles of a rigid solid,which may be a soluble crystalline material, for example, in the polymerbefore it is place on the screen. Polymers having varying degradationrates may be used on different areas of a screen. For example, a morerapidly degrading polymer may be used over the lower portion of ascreen.

Degradable polymer, such as PLA, may be applied to the screen, forexample, by heating the polymer to allow flow or extrusion and coatingthe polymer on the finished screen. The screen may be heated beforeapplication of the polymer to allow more uniform flow of polymer intothe screen. Alternatively, the polymer may be applied from solution in asolvent and the solvent removed to form a solid polymer. Alternatively,the base pipe or mandrel of the screen may be coated and the holesplugged with hot PLA or other water-degradable polymer before the wireof a screen is applied. Alternatively, blank pipe to be run into a wellmay be coated with the degradable polymer. The degradable polymer may beformulated to contain any or all the additives taught by the '919Publication. The additives would then be release to enter the fluidsaround the screen or blank pipe as the polymer degrades.

There are reasons to attached various mechanical devices to the outsideof tubulars as they are placed in a well. The devices may be used tomeasure physical or chemical variables or to modify flow conditions inthe well, for example. A change in the position, status or operation ofthe device after a selected time may be desirable. A degradable polymer,such as PLA or a PHA, may be used to form a mechanical part of thedevice or a support for the device. The degradation rate of thedegradable polymer may be selected to allow the desired change to occurin a selected range of time after placement of the device in a well. Forexample, FIG. 3 is adapted from U.S. Pat. No. 5,509,474. In thisexample, tubing 106 has been placed in a well inside casing 12. Theannulus between tubing and casing will ordinarily be filled by anaqueous fluid. Sensors 111 are designed to be released from the vicinityof the outside surface of tubing 106 and then to spring against theinside wall of casing 12. An electromechanical device could be used torelease the spring-loaded sensors. Alternatively, groove 200 may beformed in insulating material collar 114 and the spring-loaded sensorsmay be held in groove 200 by placing a selected solid water-degradablepolymer over the sensor, shown at 111(a), in the groove, usingtechniques of placement such as described above for a screen. Aftertubing 106 is placed in a well in an aqueous fluid environment, polymerin groove 200 degrades to a range of mechanical properties (determinedby the decrease in molecular weight of the degradable polymer) thatallows sensor 111 to be released and to spring into the position shownat 111, which is in contact with the inside surface of casing 12.

The applications of degradable polymers disclosed herein to allow atimed change in location of a part or parts of mechanical devices can bereadily seen by one of skill in the art of each device. The degradablepolymer may easily be configured to allow the change to occur ascompressive strength of the polymer degrades, as tensile strengthdegrades, as bending strength degrades, or as a combination ofproperties changes. The time of change can be determined by selecting adegradable polymer that changes in properties at a rate to allow thechange to occur in a desired time range. This range may be hours, daysor months, depending on the mechanical configuration and the polymerselected.

In other applications, flow configuration or pressure changes may bedesired in a well after a selected time. For example, a port maypreferably be opened after a selected time, in the range of hours, daysor months. The port may be inaccessible or require expensive operationsto open. For example, the port may be used to co-mingle fluid streamsbeing produced from a well and be in an aqueous environment. A plug maybe formed from a degradable polymer as disclosed herein. Tests can beperformed with different polymer compositions to select the polymerproviding the opening of the port in the desired time range and at thepressure differential existing across the port when in the well.Measurements of physical properties of a selected degradable polymer asa function of time and at selected temperatures in an aqueousenvironment may also be used to predict the time of opening of aselected port under selected conditions. Alternative, the polymer can bemade in the form of a seal or gasket that degrades in time to allowflow. Such measurements and tests should take into account thedimensions of the degradable polymer body that is degrading, since suchchanges in properties are known to be affected by dimensions of thebody, which affect the length of the diffusion path of water moleculesinto the degradable material and the diffusion path of reaction productsfrom the polymer.

In another embodiment, mechanical devices or selected parts ofmechanical devices that are placed in a well may be formed from soliddegradable polymer such as PLA or PHA. For example, parts of a packer, abridge plug or a cement retainer may be formed of water-degradablepolymer. After a selected range of time, from hours, to days or months,the device or selected parts of the device may be designed to decreasein properties so as to release the device and facilitate retrieval.Alternatively, the entire device may be formed of a degradable polymerwhere strength of the polymer is adequate. For example, a nipple or pipesection may be formed of degradable polymer. The nipple or pipe maydegrade and later be produced from a well. The pipe may be the “tailpipe” used in a sand control screen, for example.

Whereas the PLA used in fluids is preferably amorphous, as describedabove, the PLA used in mechanical or flow control devices may beamorphous or crystalline. The bending strength of rods of poly(D-lactide) (PLA) (which would be crystalline) when made by routineinjection molding has been measured to be in the range of 40-140 MPA.Rods formed by solid state extrusion had bending strengths up to 200 MPA(“Enhancement of the mechanical properties of polylactides bysolid-state extrusion,” Biomaterials 17, (March, 1996, 529-535). Furtherinformation about PLA and its properties is provided in a chapterentitled “Present and Future of PLA Polymers” in the book DegradablePolymers, Recycling, and Plastics Waste Management, Ed. by Ann-ChristineAlbertsson and S. J. Huang, Marcel Dekker, Inc. It is well known thatstrength may be increased by the use of composites made of thethermoplastic polymer. Where added strength is desired, composite formedfrom a degradable polymer may be used. PLA, for example, can be moldedas other thermoplastic materials are formed or it may be formed byextrusion other processing steps known in industry.

An example of a simple mechanical device that may be formed or partiallyformed from PLA or other water-degradable polymer is a flotationcontainer to be attached to casing being run into a horizontal well.Such flotation devices made of metal are well known. The walls and endsof such a container may be formed from degradable polymer, with adequatesupports of degradable polymer between the ends to prevent collapse, orthe ends and supports may be formed of degradable polymer and designedto allow walls to collapse after a selected time in the well (and beforecementing).

Other mechanical parts that may be more easily left in a well thanretrieved may also be formed from degradable polymer such as PLA. Forexample, the case or container of perforating devices may be formed ofdegradable polymer. After a selected time, the device may then be easilyflowed from the well, if desired.

Although the present invention has been described with reference tospecific details, it is not intended that such details should beregarded as limitations on the scope of the invention, except as and tothe extent that they are included in the accompanying claims.

What I claim is:
 1. A sand control screen having a solid hydrolyticallydegradable polymeric coating, the polymer comprising a polyester, thecoating covering the screen to initially prevent entry of particles orfluid flow into or out of the screen.
 2. The sand control screen ofclaim 1 wherein the solid hydrolytically degradable polymer comprisespolylactic acid.
 3. The sand control screen of claim 1 wherein the solidhydrolytically degradable polymer further comprises a solid material toincrease strength of the polymer coating.
 4. The sand control screen ofclaim 3 wherein the solid hydrolytically material is a soluble material.5. The sand control screen of claim 1 wherein the solid hydrolyticallydegradable polymer further comprises a chemical to be released to enterfluids around the screen as the polymer degrades.
 6. The sand controlscreen or liner of claim 1 further comprising a plurality ofhydrolytically solid degradable polymers having varying degradationrates on different areas of the screen.
 7. A sand control screen orslotted well liner having a base pipe or mandrel with apertures thereinplugged with a solid hydrolytically degradable polymer, the polymercomprising a polyester.
 8. The sand control screen or slotted well linerof claim 7 wherein the solid hydrolytically degradable polymer comprisespolylactic acid.
 9. The sand control screen or slotted well liner ofclaim 7 wherein the solid hydrolytically degradable polymer furthercomprises a chemical to be released to enter fluids around the screen orliner as the polymer degrades.
 10. A slotted well liner having a solidhydrolytically degradable polymeric coating, the polymer comprising apolyester, the coating covering the slotted well liner to initiallyprevent entry of particles or fluid flow into or out of the slotted wellliner.
 11. Slotted liner of claim 10 wherein the solid hydrolyticallydegradable polymer comprises polylactic acid.
 12. The slotted well linerof claim 10 wherein the solid hydrolytically degradable polymer furthercomprises a solid material to increase strength of the polymericcoating.
 13. The slotted well liner of claim 12 wherein the solidmaterial is a soluble material.
 14. The slotted well liner of claim 10wherein the solid hydrolytically degradable polymer further comprises achemical to be released to enter fluids around the slotted well liner asthe polymer degrades.
 15. The slotted well liner of claim 10 furthercomprising a plurality of solid hydrolytically degradable polymershaving varying degradation rates on different areas of the slotted well.16. The sand control screen of claim 1 wherein the polyester polymer isselected so as to degrade no longer than thirty days from initialplacement in the well.
 17. The slotted well liner of claims 10 whereinthe polyester polymer is selected so as to degrade no longer than thirtydays from initial placement in the well.